Methods and systems for in-line mixing of hydrocarbon liquids

ABSTRACT

Methods and systems of admixing hydrocarbon liquids from a plurality of tanks into a single pipeline thereof. The system may include two or more tanks positioned at a tank farm each containing a hydrocarbon liquid therein. The system may include two or more first main pipes, each connected to one of the tanks. The system may include two or more main valves, each connected to one of the first main pipes. The system may include two or more second main pipes each connected to a corresponding main valve. The system may include two or more mixing jumpers, each connected to a corresponding first main pipe, each mixing jumper to, when a corresponding main valve is closed, control hydrocarbon liquid. The system may include a mixing pipe, connected to the second main pipes and the mixing jumpers, configured to transport hydrocarbon liquid from one or more of the tanks.

CROSS-REFERENCE TO RELATED APPLICATIONS

The present application claims priority to and the benefit of U.S.Application No. 63/265,458, filed Dec. 15, 2021, titled “METHODS ANDSYSTEMS FOR IN-LINE MIXING OF HYDROCARBON LIQUIDS” and U.S. ApplicationNo. 63/265,425, filed Dec. 15, 2021, titled “METHODS AND SYSTEMS FORIN-LINE MIXING OF HYDROCARBON LIQUIDS”, the disclosures of which areincorporated herein by reference in their entireties. The presentapplication is also a Continuation-in-Part of U.S. application Ser. No.17/566,768, filed Dec. 31, 2021, titled “METHODS AND SYSTEMS FORSPILLBACK CONTROL OF IN-LINE MIXING OF HYDROCARBON LIQUIDS”, which is acontinuation of U.S. application Ser. No. 17/247,880, filed Dec. 29,2020, titled “METHODS AND SYSTEMS FOR INLINE MIXING OF HYDROCARBONLIQUIDS BASED ON DENSITY OR GRAVITY”, now U.S. Pat. No. 11,247,184,issued Feb. 15, 2022, which is a Continuation-in-Part of U.S.application Ser. No. 17/247,700, filed Dec. 21, 2020, titled “METHODSAND SYSTEMS FOR INLINE MIXING OF HYDROCARBON LIQUIDS BASED ON DENSITY ORGRAVITY”, which claims priority to and the benefit of U.S.

Provisional Application No. 63/198,356, filed Oct. 13, 2020, titled“METHODS AND SYSTEMS FOR INLINE MIXING OF PETROLEUM LIQUIDS,” U.S.Provisional Application No. 62/705,538, filed Jul. 2, 2020, titled“METHODS AND SYSTEMS FOR INLINE MIXING OF PETROLEUM LIQUIDS”, and U.S.Provisional Application No. 62/954,960, filed Dec. 30, 2019, titled“METHOD AND APPARATUS FOR INLINE MIXING OF HEAVY CRUDE”, the disclosuresof which are incorporated herein by reference in their entirety. U.S.application Ser. No. 17/247,880 is also a Continuation-in-Part of U.S.application Ser. No. 17/247,704, filed Dec. 21, 2020, titled “METHODSAND SYSTEMS FOR INLINE MIXING OF HYDROCARBON LIQUIDS”, now U.S. Pat. No.10,990,114, issued Apr. 27, 2021, which claims priority to and thebenefit of U.S. Provisional Application No. 63/198,356, filed Oct. 13,2020, titled “METHODS AND SYSTEMS FOR INLINE MIXING OF PETROLEUMLIQUIDS,” U.S. Provisional Application No. 62/705,538, filed Jul. 2,2020, titled “METHODS AND SYSTEMS FOR INLINE MIXING OF PETROLEUMLIQUIDS”, and U.S. Provisional Application No. 62/954,960, filed Dec.30, 2019, titled “METHOD AND APPARATUS 57019984v1 FOR INLINE MIXING OFHEAVY CRUDE”, the disclosures of which are incorporated herein byreference in their entireties.

FIELD OF DISCLOSURE

The disclosure herein relates to systems and methods for providingin-line mixing of hydrocarbon liquids using mixing jumpers, and one ormore embodiments of such systems and methods may be suitable forproviding multi-component mixing of two or more hydrocarbon liquids.

BACKGROUND

Different types of hydrocarbon liquids, such as petroleum and renewableliquid products (e.g., such as crude oil), are often mixed upstream of arefinery to reduce the viscosity of heavy crude and maximize capacity,or to create a desired set of properties (TAN, sulfur, etc.). Given themultitude of crude types, the potential mixtures and component ratiosare numerous. In some situations, multiple different types ofhydrocarbon liquids, e.g., crude oil and renewable products, fromdifferent tanks may need to be mixed in a particular ratio. Further,there may also be a need to create a desired mixture on demand and shipthe mixture through a pipeline as one homogenous product. In suchexamples, the mixing of different types of hydrocarbon liquid, e.g.,crude and renewable liquid, may be performed at a pipeline originationstation. Often, the pipeline origination station may include a tank farm(e.g., having multiple tanks for storage and mixing of the crude oils)and extensive piping capable of transporting hydrocarbon liquids fromeach of the tanks to one or more mainline booster pumps, which raise thehydrocarbon liquids to high pressures for traveling on a long pipeline.

Historically, crude mixing occurred by blending the crude oils in one ormore tanks. Tank mixing is the most common form of crude mixing in theoil and gas industry. While relatively inexpensive, such methods haveseveral undesirable drawbacks. For example, the extent and/or accuracyof the mixing may be less precise (e.g., having an error rate of+/−about 10% based on a target set point). Such methods typicallyrequire an entire tank to be dedicated to blending the crude oils alongwith separate distribution piping therefrom. In addition, the mixedcrude product tends to stratify in the tank without the use of tankmixers, which also require additional capital investment. Further, themixed crude product is generally limited to a 50/50 blend ratio.

An alternative to tank mixing is parallel mixing, which uses two pumpsto pump two controlled feed streams (e.g., one pump per feed stream) ondemand from separate tanks and into the pipeline. While parallel mixingis typically more precise than tank mixing, it is also more difficult tocontrol because both streams are pumped by booster pumps into a commonstream. Typically, the two pumped streams are individually controlled byvariable speed pumps or pumps with flow control valves; therefore, thetwo sets of independent controls may interfere with each other and/ormay have difficulty reaching steady state if not programmed correctly.

Applicant has recognized, however, that in parallel mixing operations,both streams need to be boosted to about 50-200 psi of pressure in thetank farm to provide adequate suction pressure to a mainline boosterpump that is positioned downstream of the boosters. Even if one streamoperates at a fixed flow while the other varies, the need to boost thepressure of each stream to about 50-200 psi may require high horsepowerboost pumps dedicated to each line. Such dedicated pumps may be neededto supply streams at adequate pressure to the mainline pumps and mayrequire significant capital investment. From a commercial standpoint,for example, parallel mixing operations require much moreinfrastructure, representing a 180% to 200% increase in cost differencecompared to the in-line mixing systems disclosed herein. Therefore,there is a need in the industry for accurate and cost-effective blendingmethods and systems for crude and other hydrocarbon liquid products.

SUMMARY

The disclosure herein provides embodiments of systems and methods forin-line fluid mixing of hydrocarbon liquids. In particular, in one ormore embodiments, the disclosure provides for in-line mixing via mixingjumpers from tanks positioned at a tank farm. Such systems and methodsmay enable each of two or more tanks to provide a single hydrocarbonliquid as a product, via a larger pipeline, or enable two of the two ormore tanks to provide a blend of hydrocarbon liquids as a blendedproduct via corresponding mixing jumpers. In other words, the in-linemixing system is positioned to admix two or more of those hydrocarbonliquids contained within the two or more of tanks to provide a blendedmixture within a single pipeline. In some embodiments, the systems andmethods of the disclosure may provide for in-line mixing of at least twohydrocarbon liquids, at least three hydrocarbon liquids, or more to forma blended fluid flow in a single pipeline, e.g., which may be referredto herein as two-component blend, three-component blends, or a blendcontaining more than three hydrocarbon liquids. Further, suchembodiments, may provide the blended mixture efficiently and utilizing alow or a minimal amount of power.

The mixing jumpers utilized in such operations may be comprised ofpipes, an isolation valve, a meter and/or sensor, and/or a flow controldevice. The flow control device may be a control valve. Other devicesmay be utilized such as a turbine, a pump (e.g., a variable speed pumpor fixed pump), a control valve and pump, or some combination thereof.The mixing jumper may allow fluid to flow therethrough when theisolation valve is opened. In an embodiment, opening the isolation valveprevents flow through a corresponding tank's main pipe. In anotherembodiment, the tank's main pipe may include an isolation valve toprevent/allow fluid to flow therethrough. The meter and/or sensor maydetermine the amount of fluid flowing through, or some othercharacteristics or aspect of the fluid, the mixing jumper. The meterand/or sensor may be a flow meter and/or a pressure sensor. Other metersand/or sensors may be positioned throughout the system, such as tanklevel meters, temperature sensors, and/or other flow meters or pressuresensors. The flow control device may allow for control of a final blend.For example, a blend may include 40% of a fluid from tank A and 60% ofanother fluid from tank B. In such examples, the flow control devicesmay adjust to drive the blend to a correct ratio, based on measurementsfrom, at least, the meter and/or sensor.

Accordingly, an embodiment of the disclosure is directed to an in-linefluid mixing system. The in-line fluid mixing system may be positionedat a tank farm to admix hydrocarbon liquids from a plurality of tanksinto a single pipeline. The in-line fluid mixing system may comprise twoor more tanks positioned at a tank farm with at least one tankcontaining a hydrocarbon liquid therein. The in-line fluid mixing systemmay comprise two or more first main pipes. Each one of the two or moremain pipes may be connected to one of the two or more tanks. The in-linefluid mixing system may comprise two or more main valve. Each of the twoor more main valves may be connected to one of the two or more mainpipes. The hydrocarbon liquid may flow from one tank through one firstmain pipe to a corresponding main valve. The in-line fluid mixing systemmay comprise two or more second main pipes. Each one of the two or moresecond main pipes may be connected to a corresponding main valve. Thein-line fluid mixing system may comprise two or more mixing jumpers.Each of the mixing jumpers may be connected to a corresponding firstmain pipe of the two or more first main pipes. Each of the two or moremixing jumpers may, when a corresponding main valve is closed, controlhydrocarbon liquid flowing from two or more tanks. The in-line fluidmixing system may comprise a mixing pipe or a header connected to eachof the two or more second main pipes and each of the two or more mixingjumpers. The mixing pipe may be configured to transport hydrocarbonliquid from one or more of the two or more tanks. The in-line fluidmixing system may include one or more controllers in signalcommunication with the isolation valve, the sensor, and the flow controldevice of each of the mixing jumpers and with each of the one or moremain valves. The one or more controllers may control the flow controldevice for each of the one or more mixing jumpers thereby to control anamount of hydrocarbon liquid flowing therethrough. Such control may bebased on one or more of a specified hydrocarbon liquid blend percentageand a current flow rate, from a corresponding sensor, of a specifiedhydrocarbon liquid flowing from a specified tank

The mixing jumpers described above may include an isolation valve to,when closed, prevent hydrocarbon liquid to flow therethrough and, whenopen, allow hydrocarbon liquid to flow therethrough. Further, the mixingjumper, may include a sensor to determine a characteristic (e.g., flowrate, pressures, temperature, viscosity, and/or other characteristics)of hydrocarbon liquid flowing through the one of the one or more mixingjumpers. The sensor may include one or more of a flow meter, densitysensor, pressure sensor or transducer, or a temperature sensor. Themixing jumper may also include a flow control device to controlhydrocarbon liquid flowing through the one of the one or more mixingjumpers. The flow control device may be or include one or more of acontrol valve or a turbine. The mixing jumper may finally include amixing jumper pipe to connect the mixing jumper to the mixing pipe orcorresponding second main pipe.

In an embodiment, when one of the one or more main valves is open andhydrocarbon liquid is flowing therethrough, each of the isolation valvesfor the one or more mixing jumpers may be closed, thus preventing fluidflow through the mixing jumpers.

Another embodiment of the disclosure is directed to a method of admixinghydrocarbon liquids from two or more tanks into a single pipeline toprovide in-line mixing thereof. The method may include initiating ahydrocarbon liquid process that includes blending specified percentagesof two or more hydrocarbon liquids over a period of time each of the twoor more hydrocarbon liquids stored in one of two or more tanks. Themethod may include closing, for each one of the two or more tanks, amain valve. The method may include opening, for each one of the two ormore tanks, an isolation valve of a mixing jumper. The method mayinclude determining, for the mixing jumper of each one of the two ormore tanks, a flow rate of hydrocarbon liquid. The method may include,in response to a difference between a mix ratio and a ratio of eachdetermined flow rate of hydrocarbon liquid: (1) determining a correctedratio based on one or more of the difference between the mix ratio, theratio of each determined flow rate of hydrocarbon liquid, or one or moreof each flow rate of each hydrocarbon liquid, and (2) adjusting a flowcontrol device of the mixing jumper for each of the two or more tanksbased on the corrected ratio to modify flow rate of hydrocarbon liquidto drive the ratio towards the target ratio.

Another embodiment of the disclosure is directed to a method of admixingliquid from two or more tanks into a single pipeline to provide in-linemixing thereof. The method may include receiving blend parameters of ablend process. The blend parameters may include specified or selectedpercentages of one or more hydrocarbon liquids. The method may include,in response to blend parameters with two or more specified percentagesof two or more hydrocarbon liquids, (1) opening, for each of thecorresponding tanks, a jumper valve of a mixing jumper and (2) closing,for each of the corresponding tanks, a main valve. Each of the two ormore hydrocarbon liquids may be stored in the corresponding tanks. Themethod may further include determining, for the mixing jumper of each ofthe corresponding tanks, a flow rate of hydrocarbon liquid. The methodmay include, in response to a difference between a mix ratio and a ratioof each determined flow rate of hydrocarbon liquid, (1) determining acorrected ratio based on one or more of the difference between the mixratio, the ratio of each determined flow rate of hydrocarbon liquid, orone or more of each flow rate of each hydrocarbon liquid, and (2)adjusting a flow control device of the mixing jumper for each of thecorresponding tanks based on the corrected ratio to modify flow rate ofhydrocarbon liquid to drive the ratio towards the target ratio. In anembodiment, the corrected ratio may further be based on one or more of adensity of each of the two or more hydrocarbon liquids or a level ofhydrocarbon liquid in each of the corresponding tanks.

In another embodiment, the method may include, in response to blendparameters with a specified percentage of one hydrocarbon liquid, (1)opening, for a corresponding tank, a main actuated valve to allow theone hydrocarbon liquid to flow to a header therethrough for a selectedtime, and (2) closing, for the corresponding tank, a jumper actuatedvalve of a mixing jumper to prevent flow of the one hydrocarbon liquidthrough the mixing jumper.

Another embodiment of the disclosure is directed to a controller for anin-line mixing system for admixing hydrocarbon liquids from one or moretanks into a single pipeline via mixing jumpers. The controller mayinclude a first input in signal communication with a first meter tomeasure a first flow rate of the first liquid. The first meter may bepositioned along a first mixing jumper that is connected to a firsttank. The controller may be configured, in relation to the first input,to obtain the first flow rate from the first meter via the first inputafter initiation of a blending operation. The controller may include asecond input in signal communication with a second meter to measure asecond flow rate of the second liquid. The second meter may bepositioned along a second mixing jumper that is connected to a secondtank. The controller may be configured to, in relation to the secondinput, obtain the second flow rate from the second meter via the secondinput after initiation of the blending operation. The controller mayinclude an input/output in signal communication with a first controlvalve and a second control valve. The first control valve may bedesigned to adjust flow of the first liquid via the first mixing jumperthereby modifying the first flow rate. The second control valve may bedesigned to adjust flow of the second liquid via the second mixingjumper thereby modifying the second flow rate. The controller, inrelation to the input/output, may be configured to, after initiation ofthe blending operation: (1) determine whether one or more of the firstflow rate or the second flow rate are to be modified based on one ormore of a target mix ratio, a ratio of the first flow rate and secondflow rate, the first flow rate, or the second flow rate; and (2) inresponse to a determination that the first flow rate is to be modified,adjust a position of the first flow control valve that adjusts flowthrough the first mixing jumper, thereby modifying the first flow rate;and (3) in response to a determination that the second flow rate is tobe modified, adjust a position of the second flow control valve thatadjusts flow through the second mixing jumper, thereby modifying thesecond flow rate.

Still other aspects and advantages of these embodiments and otherembodiments, are discussed in detail herein. Moreover, it is to beunderstood that both the foregoing information and the followingdetailed description provide merely illustrative examples of variousaspects and embodiments, and are intended to provide an overview orframework for understanding the nature and character of the claimedaspects and embodiments. Accordingly, these and other objects, alongwith advantages and features of the present disclosure herein disclosed,will become apparent through reference to the following description andthe accompanying drawings. Furthermore, it is to be understood that thefeatures of the various embodiments described herein are not mutuallyexclusive and may exist in various combinations and permutations.

BRIEF DESCRIPTION OF THE DRAWINGS

These and other features, aspects, and advantages of the disclosure willbecome better understood with regard to the following descriptions,claims, and accompanying drawings. It is to be noted, however, that thedrawings illustrate only several embodiments of the disclosure and,therefore, are not to be considered limiting of the scope of thedisclosure.

FIG. 1A, FIG. 1B, FIG. 1C, FIG. 1D, FIG. 1E, and FIG. 1F are schematicblock diagrams of respective N-component in-line mixing systemspositioned at a tank farm to admix up to N amount of hydrocarbon liquidsfrom separate tanks into a single pipeline, according to embodiments ofthe disclosure.

FIG. 2A, FIG. 2B, FIG. 2C, and FIG. 2D are schematic block diagrams ofrespective N-component in-line mixing systems positioned at a tank farmto admix up to N amount of hydrocarbon liquids from separate tanks intoa single pipeline, according to embodiments of the disclosure.

FIG. 3A and FIG. 3B are simplified block diagrams illustrating controlsystems for managing a multi-component in-line mixing system, accordingto embodiments of the disclosure.

FIG. 4 is a flow diagram of a method for managing a multi-componentin-line mixing system, according to an embodiment of the disclosure.

FIG. 5 is another flow diagram of a method for managing amulti-component in-line mixing system according to an embodiment of thedisclosure

DETAILED DESCRIPTION

So that the manner in which the features and advantages of theembodiments of the systems and methods disclosed herein, as well asothers that will become apparent, may be understood in more detail, amore particular description of embodiments of systems and methodsbriefly summarized above may be had by reference to the followingdetailed description of embodiments thereof, in which one or more arefurther illustrated in the appended drawings, which form a part of thisspecification. It is to be noted, however, that the drawings illustrateonly various embodiments of the systems and methods disclosed herein andare therefore not to be considered limiting of the scope of the systemsand methods disclosed herein as it may include other effectiveembodiments as well.

The present disclosure provides embodiments of systems and methods forin-line fluid mixing of hydrocarbon fluids and/or liquids. “Hydrocarbonliquids” as used herein, may refer to petroleum liquids, renewableliquids, and other hydrocarbon based liquids. “Petroleum liquids” asused herein, may refer to liquid products containing crude oil,petroleum products, and/or distillates or refinery intermediates. Forexample, crude oil contains a combination of hydrocarbons havingdifferent boiling points that exists as a viscous liquid in undergroundgeological formations and at the surface. Petroleum products, forexample, may be produced by processing crude oil and other liquids atpetroleum refineries, by extracting liquid hydrocarbons at natural gasprocessing plants, and by producing finished petroleum products atindustrial facilities. Refinery intermediates, for example, may refer toany refinery hydrocarbon that is not crude oil or a finished petroleumproduct (e.g., such as gasoline), including all refinery output fromdistillation (e.g., distillates or distillation fractions) or from otherconversion units. In some non-limiting embodiments of systems andmethods, petroleum liquids may include heavy blend crude oil used at apipeline origination station. Heavy blend crude oil is typicallycharacterized as having an American Petroleum Institute (API) gravity ofabout 30 degrees or below. However, in other embodiments, the petroleumliquids may include lighter blend crude oils, for example, having an APIgravity of greater than 30 degrees. “Renewable liquids” as used herein,may refer to liquid products containing plant and/or animal derivedfeedstock. Further, the renewable liquids may be hydrocarbon based. Forexample, a renewable liquid may be a pyrolysis oil, oleaginousfeedstock, biomass derived feedstock, or other liquids, as will beunderstood by those skilled in the art. The API gravity of renewableliquids may vary depending on the type of renewable liquid.

In particular, in one or more embodiments, the disclosure provides anin-line mixing system that may be positioned at a tank farm thatincludes a plurality of tanks configured to store one or morehydrocarbon liquids. Such an in-line mixing system may provide admixingof two or more of those hydrocarbon liquids contained within theplurality of tanks to provide a blended mixture within a singlepipeline. In some embodiments, the systems and methods of the disclosuremay provide for in-line mixing of at least two hydrocarbon liquids, atleast three hydrocarbon liquids, or more than three hydrocarbon liquidsto form a blended fluid flow in a single pipeline, e.g., which may bereferred to herein as two-component blends, three-component blends, or ablend containing more than three hydrocarbon liquids. Advantageously,in-line mixing operations (sometimes referred to as “series mixing”) mayutilize one or more controlled, tank output streams (e.g., controlledvia a mixing jumper including a flow control device among other devicesand/or sensors), all of which are upstream of a common booster pump usedto pump a blended fluid stream through a pipeline. Further, the in-linemixing system may include sensors, disposed throughout the tank farm, todetermine various fluid characteristics, allowing for the in-line mixingsystem to blend the hydrocarbon liquids according to a target blendpercentage, density, and/or gravity, providing a precisely blended fluidor liquid stream. Further, based on the configuration of such an in-linemixing system, any number of component blends or simply a single fluidmay be formed or transported with low energy utilization.

In some embodiments, the systems and methods as described herein mayprovide for in-line, on-demand, blending of crude oil, other hydrocarbonliquids, and/or renewable liquids at a pipeline origination station. Apipeline origination station is typically located at or near a tank farm(e.g., having a plurality of tanks containing hydrocarbon liquids). Thepipeline origination station includes extensive piping capable oftransporting the hydrocarbon liquids from each of the nearby tanks inthe tank farm to one or more mainline booster pumps, which raise thehydrocarbon liquids to very high pressures for passage through the longpipeline. A “tank farm” as used herein, refers to a plurality of tankspositioned in an area, each of the plurality of tanks configured to holdone or more hydrocarbon liquids therein. In some embodiments, theplurality of tanks may be positioned proximate to each other or theplurality of tanks may be spread out across a larger area. In someembodiments, the plurality of tanks may be positioned sequentially suchthat each tank is equally spaced apart. Generally, the number ofindividual tanks in a tank farm may vary based on the size of thepipeline origination station and/or based on the amount of hydrocarbonliquids being stored in that facility. For example, the tank farm mayinclude at least 2, at least 4, at least 6, at least 8, at least 10, atleast 12, or more individual tanks within the tank farm.

As noted above, typical pipeline origination stations require blendingof two or more different hydrocarbon liquids in a blending tank prior topumping the blended hydrocarbon liquids from the blending tank itself.However, the systems and methods of this disclosure advantageouslyprovide in-line, on-demand mixing directly in a pipe in the tank farmprior to the blended liquid being pumped to the pipeline. Such pipeblending may eliminate stratification of mixed oil in tanks and does notrequire the use of individual tank mixers in each of the tanks. Thesesystems and methods may also eliminate the need to mix the hydrocarbonliquids in one or more tanks before the hydrocarbon liquids are pumpedtherefrom, which advantageously allows for the changing of the blendon-demand and on-demand blending during operation of the pipelineorigination station. In some embodiments, for example, a separateblending tank in the tank farm is not necessary, and thus, one or moretanks in the tank farm previously used for blending may beneficially beused for storage of additional hydrocarbon liquids, which may also beblended in-line. Further, basing blending operations on variousmeasurements of fluids to be mixed (e.g., flow and/or density orgravity) may increase accuracy and precision of blending.

Other typical pipeline origination stations may use parallel mixing oftwo or more hydrocarbon liquids, which may be expensive and of lowerefficiency. In particular, typical parallel mixing operations require adedicated high horsepower mixing booster pump (e.g., greater than 750hp, greater than 850 hp, greater than 950 hp or even greater than 1050hp) for each of the mixing streams and an additional static mixer toblend the hydrocarbon liquids pumped through each of the mixing streams.However, the systems and methods of this disclosure advantageouslyprovide cost and energy savings, because such systems and methods do notrequire high horsepower mixing booster pumps or the additional staticmixer. For example, the mixing booster pumps, if any are utilized,typically used in the mixing streams of the systems and methodsdescribed herein, have lower horsepower ratings (e.g., less than 250 hp,less than 200 hp, less than 150 hp, or even less than 100 hp). Inaddition, the in-line mixing systems, according to this disclosure, mayeliminate the need for any pumps, other than the downstream booster pumpto transport fluids to other locations, while including an amount ofisolation valves and control valves (e.g., one of each for each of thestreams). An isolation valve may include an electrically actuated valve,a hydraulically actuated valve, a manually actuatable valve, amaintenance valve, and/or any valve configured to open or close basedone or more of a transmitted signal or manual actuation. A control valvemay include a valve configured to open to various positions, based oneor more of a transmitted signal or manual actuation, to control a flowof fluid. Such isolation valves and control valves may utilize littlepower in relation to pumps, fixed or variable speed, and, in someembodiments, may utilize no power, as actuation is performed manually.The other devices utilized in such a tank farm may utilize low power aswell, e.g., sensors and/or meters. Further, in-line mixing systems asdescribed herein may provide for more accurate control of blendedhydrocarbon liquids, for example, within 1.0 percent or less of thedesired set point (e.g., desired flow rate and/or density or gravity)for the blended fluid flow.

FIG. 1A, FIG. 1B, FIG. 1C, FIG. 1D, FIG. 1E, and FIG. 1F depict processdiagrams of a non-limiting, N-component in-line mixing system positionedat a tank farm to admix up to N amount of hydrocarbon liquids fromseparate tanks into a single pipeline, according to embodiments of thedisclosure. Turning first to FIG. 1A, the in-line mixing system mayinclude two or more tanks 102A up to 102N (e.g., tank A 102A, tank B102B, and up to tank N 102N). The tanks 102A-102N may store varioushydrocarbon fluids or liquids. Such hydrocarbon fluids or liquids mayinclude petroleum liquids and/or renewable liquids. The tanks 102A-102Nmay be filled completely or partially prior to a blending operation. Inanother embodiment, during a blending operation the tanks 102A-102N maybe re-filled. Such actions may alter the flow rate from such tanks102A-102N, as well as, in some examples, the density or gravity of thehydrocarbon fluid or liquid therein. Further, as a tank empties during ablending operation, the flow rate may change (e.g., as a tank leveldecreases, the flow rate from the tank may decrease). Further still,other factors may affect flow rate from a tank, e.g., liquid viscosity,density, distance from mixing pipe 120, pipe diameter, and/or othercharacteristics. The diameter of first main pipe 104A-104N and secondmain pipe 105A-105N may be about 36 inches, while the diameter of themixing jumper pipe 110A-110N may be about 16 inches to about 17 inches,about 16 inches to about 18 inches, about 16 inches to about 19 inches,about 16 to about 20 inches, about 17 inches to about 18 inches, about17 inches to about 19 inches, about 17 to about 20 inches, about 18inches to about 19 inches, about 18 to about 20 inches, about 19 inchesto about 20 inches, about 16 inches, about 17 inches, about 18 inches,about 19 inches, or about 20 inches, thereby allowing for greatercontrol of flow from the tanks 102A-102N when utilizing the mixingjumper 116A-116N. In an embodiment, the first main pipe 104A-104N andsecond main pipe 105A-105N may be a larger or smaller than 36 inches indiameter. In such an embodiment, the mixing jumper pipe 110A-110N may besized less than first main pipe 104A-104N and second main pipe105A-105N. For example, if the first main pipe 104A-104N and second mainpipe 105A-105N include a 16-inch diameter, then the mixing jumper pipe110A-110N may be about 12 inches or less in diameter. Various othersizes of pipe may be used based on the type of blending operations to beperformed. Size of the first main pipe 104A-104N and second main pipe105A-105N may be selected to minimize pressure drop and/or increase flowof fluid.

The in-line mixing system may include pipes corresponding to each of thetanks 102A-102N. A first main pipe 104A-104N or an output pipe mayconnect, at a first end of the first main pipe 104A-104N, each of thetanks 102A-102N to an isolation valve, at second end of the first mainpipe 104A-104N. In other words, the isolation valve may be positionedalong the first main pipe 104A-104N. Fluid flowing from the tanks102A-102N may flow through the first main pipe 104A-104N to theisolation valve. As depicted in FIG. 1A, two isolation valves (e.g.,isolation valves 106A-106N and isolation valves 108A-108N) may controlflow to different pipes (e.g., second main pipe 105A-105N and mixingjumper 116A-116N, respectively). For example, isolation valves 106A-106Nmay control (e.g., prevent or allow) flow through the first main pipe104A-104N to the second main pipe 105A-105N. Isolation valves 108A-108Nmay control (e.g., prevent or allow) flow through first main pipe104A-104N to the mixing jumpers 116A-116N. In an embodiment, when oneisolation valve is open, the other isolation valve may be closed (e.g.,if isolation valve 106A-106N is open then isolation valve 108A-108N areclosed and if isolation valve 108A-108N is open then isolation valves106A-106N are closed). The isolation valves (e.g., isolation valves106A-106N and isolation valves 108A-108N) may fully open or fully close,rather than opening or closing to different positions ordegrees/percentages. In another embodiment, rather than utilizingisolation valves, the in-line mixing system may utilize control valves.Control valves, as used herein, may open or close to varying positionsor different degrees or percentages open or closed.

As noted, the in-line mixing system may include a mixing jumper116A-116N. The mixing jumper 116A-116N may control the flow from acorresponding tank 102A-102N (e.g., when two or more isolation valves106A-106N are closed and two or more isolation valves 1-8A-108N are openallowing fluid to flow from the tanks 102A-102N through the first mainpipe 104A-104N to the mixing jumper 116A-116N). In an embodiment, if onetank is providing fluid to mixing pipe 120 (e.g., isolation valve106A-106N is open and isolation valves 108A-108N is closed), then noother tank in the in-line mixing system may provide fluid to the mixingpipe 120. In other words, if the main pipe 106A-106N is in use for onetank for a blending operation (e.g., a single component blend), then noother tank may be utilized in such a blending operation, either via mainpipe or mixing jumper corresponding to the other tank.

The mixing jumper 116A-116N may include a number of devices orcomponents. The mixing jumper 116A-116N may include a mixing jumper pipe110A-110N, isolation valve 108A-108N, a meter 112A-112N, and/or controlvalve 114A-114N. The mixing jumper 116A-116N may include more or lessadditional devices or components. Further, other components may be usedin place of the components listed. For example, a pump may be utilizedrather than or in addition to the control valve 114A-114N. In anotherembodiment, a turbine may be utilized rather than or in addition to thecontrol valve 114A-114N. In such an embodiment, the turbine may controlthe flow rate through the mixing jumper 116A-116N, while in turngenerating electrical power. Such electrical power may be utilized topower devices or components of the in-line mixing system or may bestored in on-site energy storage devices (e.g., batteries or capacitorbased energy storage devices). Further, in such embodiments, theturbines may limit flow therethrough based on a gearbox corresponding tothe turbine or based on a variable resistance rotor, or some combinationthereof.

In an embodiment, once a blend operation is initiated isolation valves106A-106N may close and isolation valves 108A-108N corresponding totanks 102A-102N utilized in the blending operation may be opened,allowing fluid to flow from selected tanks 102A-102N through the firstmain pipe 104A-104N and isolation valve 108A-108N to the mixing jumpers116A-166N. The control valves 114A-114N corresponding to tanks 102A-102Nutilized in the blending operation may be opened to a specifiedposition, based on, for example, the percentage of fluids to be blended.As a blending operation begins, flow rates, as noted above, may varyover time, potentially altering the blend percentage. As such, eachmixing jumper 116A-116N may include a meter 112A-112N or sensor tomeasure one or more characteristics of the fluid flowing from acorresponding tank 102A-102N. For example, the meter 112A-112N maymeasure the flow rate from the corresponding tank 102A-102N. Acontroller (e.g., controller 122 as depicted in FIG. 1D) may receive theflow rate and/or other characteristic as measured by each meter112A-112N or other sensors. Based on the flow rates, the controller(e.g., controller 122) may determine a current blend ratio (e.g., theamount of fluid being blend from each tank in relation to the totalblend). The controller may compare the current ratio to a specifiedblend ratio. Based on a difference between the current ratio and thespecified blend ratio, the controller may transmit a signal tocorresponding control valves 114A-114N indicating a position that eachcontrol valve 114A-114N may adjust to. Such measurements and adjustmentsmay occur continuously, substantially continuously, or at specified timeintervals.

As depicted in FIGS. 1A-1E, the mixing jumper 116A-116N may include aninlet to connect to the first main pipe 104A-104N and an outlet todirectly connect to the mixing pipe 120. The mixing pipe 120 maycomprise a pipe of a different or the same diameter as the first mainpipe 104A-104N and second main pipe 105A-105N (e.g., about 36 inches) orthe mixing jumper pipe 110A-110N (e.g., about 30 inches or less or someother diameter less than that of the first main pipe 104A-104N andsecond main pipe 105A-105N).

As depicted in FIG. 1B, the in-line mixing system may include oneisolation valve 106A-106N positioned along the main pipe, while omittingisolation valve 108A-108N. As such, when the isolation valve 106A-106Nis open, fluid may flow through the first main pipe 104A-104N and secondmain pipe 105A-105N. When the isolation valve 106A-106N is closed, fluidmay flow through the mixing jumper 116A-116N.

As depicted in FIG. 1C, the in-line mixing system may include othermeters or sensors disposed in varying other locations. The in-linemixing system may include tank meters 124A-124N to measure the level ina corresponding tank 102A-102N. The level of a tank may change over timebased on various actions (e.g., fluid flowing from a tank or fluidfilling the tank). The tank level may offer an indication of the flowrate or how a flow rate may change to a controller 122. Based on such anindication, the controller 122 may send signals to control valves114A-114N to adjust to maintain a particular blend ratio during a two ormore component blending operation. The in-line mixing system mayadditionally include a meter and/or sensor 126A-126N downstream of acorresponding tank 102A-102N. Such meters and/or sensors 126A-126N maymeasure some other characteristic of the fluid, e.g., flow, viscosity,density, pressure, temperature, and/or some other characteristic. Basedon such measurements, the controller 122 may transmit signals to thecontrol valves 114A-114N to adjust to maintain a particular blend ratioduring a two or more component blending operation based on theadditional measurements and/or characteristics of the fluids.

In an example, the meters and/or sensors positioned throughout thein-line mixing system may be hydrometers, gravitometers, densitometers,density measuring sensors, gravity measuring sensors, pressuretransducers, flow meters, mass flow meters, Coriolis meters,viscometers, optical level switches, ultrasonic sensors, capacitancebased sensors, other measurement sensors to determine a density,gravity, flow, tank level, or other variable as will be understood bythose skilled in the art, or some combination thereof. In such examples,the meters and/or sensors may measure the density and/or gravity of aliquid, the flow of the liquid, the pressure of the liquid, theviscosity of the liquid, and/or a tank level. As noted above, thecontroller 122 may be in signal communication with the sensors ormeters. The controller 122 may poll or request data from the metersand/or sensors at various points in a blending operation or process. Themeter and/or sensor may be in fluid communication with a liquid tomeasure the density, gravity, or flow rate or may indirectly measuredensity, gravity, or flow rate (e.g., an ultrasonic sensor). In otherwords, the sensor or meter may be a clamp-on device to measure flowand/or density indirectly (such as via ultrasound passed through thepipe to the liquid).

As depicted in FIG. 1F, rather than or in addition to the mixing jumpers116A-116N utilizing a control valve, the mixing jumpers 116A-116N mayutilize a flow control device 130A-130N (also referred to as amechanical flow controller, a flow control apparatus, and/or flowcontrol subsystem). The flow control device 130A-130N may include apump, a meter, a pressure transducer, a flow control valve, and/or somecombination thereof. In another example, any of the meters and/orsensors of the in-line mixing system may be included with or a part ofthe flow control device 130A-130N. In such examples, each component ofthe flow control device 130A-130N may be in signal communication withthe controller 122. The flow control device 130A-130N may allow for mixratio adjustments of the liquids being blended thereby to adjust a blendratio. For example, the flow control device 130A-130N may, as noted,include a flow control valve. The flow control valve may adjust the flowand/or pressure of the liquid based on opening or closing/pinching theflow control valve. In another example, the flow control device130A-130N may include a pump and variable speed drive. The variablespeed drive may increase/decrease the speed of the pump toincrease/decrease the flow rate of a liquid to adjust the ratio ofliquids to be blended.

The in-line mixing system, as noted may include a mixing pipe 120. Themixing pipe 120 may include one or more connections to allow connectionsbetween the mixing pipe 120 and corresponding main pipes 104A-104Nthereby enabling fluid communication between the mixing pipe 120 andcorresponding main pipes 104A-104N. A booster pump 118 may be positioneddownstream of each connection thereby pumping blended fluid to alocation further downstream. The mixing pipe 120 may be a header. Aheader may be defined as a pipe arrangement that connects flowlines fromseveral sources (e.g., tanks 102A-102N) into a single gathering line. Inanother embodiment, the mixing pipe 120 may include, for example, astatic in-line mixing element or other mixing element configured tofurther incorporate and/or blend two or more fluids.

In an embodiment, the ratio of the flow of a second fluid to the flow ofa first fluid, and potentially third, fourth, or more fluids, may bereferred to herein as the mix ratio or blend ratio of the blended fluidflow. In some embodiments, the mix ratio may be varied in the range ofabout 1:99 (second fluid: first fluid) to about 99:1 (second fluid:first fluid). For example, in some embodiments, the blended fluid flowmay include the flow of the second fluid in an amount of at least 5percent, at least 10 percent, at least 15 percent, at least 20 percent,at least 25 percent, at least 30 percent, at least 35 percent, at least40 percent, at least 45 percent, at least 50 percent, at least 55percent, at least 60 percent, at least 65 percent, at least 70 percent,at least 75 percent, at least 80 percent, at least 85 percent, at least90 percent, at least 95 percent, or more. In some embodiments, theblended fluid flow may include the flow of the first fluid in an amountof at least 5 percent, at least 10 percent, at least 15 percent, atleast 20 percent, at least 25 percent, at least 30 percent, at least 35percent, at least 40 percent, at least 45 percent, at least 50 percent,at least 55 percent, at least 60 percent, at least 65 percent, at least70 percent, at least 75 percent, at least 80 percent, at least 85percent, at least 90 percent, at least 95 percent, or more. Varyingpercentages for multi-component blends may be utilized, e.g., 60:30:10,30:30:40, 20:20:20:20, etc.

FIG. 2A, FIG. 2B, FIG. 2C, and FIG. 2D depict process diagrams of anon-limiting, N-component in-line mixing system positioned at a tankfarm to admix up to N amount of hydrocarbon liquids from separate tanksinto a single pipeline, according to embodiments of the disclosure. Thein-line mixing system of FIGS. 2A-2D include similar or the samecomponents as those illustrated in FIGS. 1A-1F. For example, the in-linemixing system of FIGS. 2A-2D may include a plurality of tanks, such astank A 102A, tank B 102B, and up to tank N 102N. Each of the tanks102A-102N may include an outlet or port connected to a first end of afirst main pipe 104A-104N. The first main pipe 104A-104N may connect tothe inlets of two isolation valves, e.g., an isolation valve 106A-106Nfor single component blends and an isolation valve 108A-108N of a mixingjumper 202A-202N for multiple component blends.

For example, if a multiple component blend is specified for a particularblend or blending operation, each isolation valve 106A-106Ncorresponding to tanks 102A-102N utilized in the blend or blendingoperation may be closed, while the isolation valves 108A-108Ncorresponding to tanks 102A-102N utilized in the blend or blendingoperation may be opened. In such an example, fluid may flow from thetanks 102A-102N through the first main pipe 104A-104N to the isolationvalve 108A-108N and through the isolation valve 108A-108N into themixing jumper 202A-202N. The mixing jumpers 202A-202N may then adjustcontrol valves 114A-114N to drive the blend or mixture in the mixingpipe 120 to a specified blend ratio (e.g., based on characteristicsprovided by meters 112A-112N and/or other meters and/or sensorpositioned throughout the in-line mixing system).

Rather than the outlet of the mixing jumper 202A-202N connecting at apoint along the mixing pipe 120, the mixing jumper 202A-202N may connectat a point along the second main pipe 105A-105N downstream of theisolation valve 106A-106N. In other words, flow of fluid may becontrolled via a mixing jumper 202A-202N bypassing the isolation valve106A-106N. In such examples, the fluid flowing from the mixing jumpers202A-202N may flow to the second main line 105A-105N at a pointdownstream of the isolation valve 106A-106N. Further, the particularconnection point (e.g., along the second main pipe 105A-105N or mixingpipe 120) may be determined based on physical factors of the in-linemixing system. For example, the mixing jumper 202A-202N may bepositioned at a substantial distance from the mixing pipe 120 (e.g., 50feet, 100 feet, 200 feet, 300 feet, or even further). As such, running apipe from the mixing jumper 202A-202N to the mixing pipe 120 may not beeconomical or, in some cases, physically possible. While theconfiguration described and depicted for FIGS. 1A-1F may depict themixing jumper 116A-116N (e.g., from the mixing jumper pipe 110A-110N tothe mixing pipe 120), the configuration of the in-line mixing system forFIGS. 2A-2D may utilize less material (e.g., pipe). Further, theconfiguration in FIGS. 2A-2D may be utilized when space or real estateis limited at a site or tank farm. For example, a mixing pipe or headerat an existing tank farm may include little to no available space basedon current pipe connections. As such, the configurations depicted inFIGS. 2A-2D may be a configuration to utilize space apart or separatefrom the mixing pipe or header.

In an embodiment, the mixing jumpers 202A-202N of FIGS. 2A-2D or themixing jumpers 116A-116N of FIGS. 1A-1F may be included in kits to beadded to existing tank farm infrastructure. Such a kit may include eachcomponent and/or part illustrated of the mixing jumpers 202A-202N ofFIGS. 2A-2D or the mixing jumpers 116A-116N of FIGS. 1A-1F. In anotherembodiment, the mixing jumpers 202A-202N of FIGS. 2A-2D or the mixingjumpers 116A-116N of FIGS. 1A-1F may be constructed or installed alongwith a newly constructed tank farm. In yet another embodiment, sometanks at a tank farm may include the mixing jumpers 202A-202N of FIGS.2A-2D or the mixing jumpers 116A-116N of FIGS. 1A-1F, while other tanksmay not. In such embodiments, some tanks at the tank farm may providegravity-fed streams, via pipe sized similarly to the mixing jumper pipeused in the mixing jumpers, to the mixing pipe 120.

Further, FIG. 2D illustrates an in-line mixing system with a controller122 and additional meters and/or sensors (e.g., tank meter 124A-124N andmeters and/or sensors 126A-126N). Such meters and/or sensors may beutilized by the controller 122 to determine how to adjust the controlvalves 114A-114N to utilized in a blend or blending operation. Inanother embodiment, a meter or sensor may be positioned downstream ofwhere the mixing jumper 202A-202N connects to the second main pipe105A-105N, rather than in the mixing jumper 202A-202N. In such examples,the meter or sensor may, in addition to determining characteristics of afluid from the mixing jumper 202A-202N, determine the samecharacteristic flowing through the isolation valve 106A-106N. Anothermeter or sensor may be positioned along the mixing pipeline 120, forexample, immediately upstream or downstream of the booster pump 118.Such a meter or sensor may be utilized by the controller 122 todetermine additional characteristics of a blend or mixture to beutilized in a blend or blending operation.

FIG. 3A and FIG. 3B are simplified diagrams illustrating control systemsfor managing a multi-component in-line mixing system, according to anembodiment of the disclosure. The control system, as described herein,may be a controller 302, one or more controllers, a PLC, a SCADA system,a computing device, and/or other components to manage a blendingoperation. The controller 302 may include one or more processors (e.g.,processor 304) to execute instructions stored in memory 306. In anexample, the memory 306 may be a machine-readable storage medium. Asused herein, a “machine-readable storage medium” may be any electronic,magnetic, optical, or other physical storage apparatus to contain orstore information such as executable instructions, data, and the like.For example, any machine-readable storage medium described herein may beany of random access memory (RAM), volatile memory, non-volatile memory,flash memory, a storage drive (e.g., hard drive), a solid state drive,any type of storage disc, and the like, or a combination thereof. Asnoted, the memory 306 may store or include instructions executable bythe processor 304. As used herein, a “processor” may include, forexample one processor or multiple processors included in a single deviceor distributed across multiple computing devices. The processor 304 maybe at least one of a central processing unit (CPU), asemiconductor-based microprocessor, a graphics processing unit (GPU), afield-programmable gate array (FPGA) to retrieve and executeinstructions, a real time processor (RTP), other electronic circuitrysuitable for the retrieval and execution instructions stored on amachine-readable storage medium, or a combination thereof.

As used herein, “signal communication” refers to electric communicationsuch as hard wiring two components together or wireless communication,as understood by those skilled in the art. For example, wirelesscommunication may be Wi-Fi®, Bluetooth®, ZigBee, forms of near fieldcommunications, or other wireless communication methods as will beunderstood by those skilled in the art. In addition, signalcommunication may include one or more intermediate controllers, relays,or switches disposed between elements that are in signal communicationwith one another.

As noted, the memory 306 may store instructions executable by theprocessor 304. The instructions may include instructions 308. Suchinstructions 308 may determine various characteristics of fluid flowingwithin the in-line mixing system 300. The controller 302 may pollvarious meters and/or sensors positioned throughout the in-line mixingsystem 300 continuously, substantially continuously, or at a specifiedinterval. For example, and as illustrated in FIG. 3A, the controller 302may receive measurements from meters 316A-316N, e.g., via an input. Asillustrated in FIG. 3B, the controller may receive, in addition to orseparate from measurements from meters 316A-316N, measurements from tankmeters 326A-326N and/or meters/sensors 324A-324N, e.g., via an input.Such measurements may include a tank level, flow rates of fluids atvarious points within the in-line mixing system 300, density or gravityof each liquid within the in-line mixing system 300, temperature and/orviscosity of each liquid within the in-line mixing system 300, and/orany other relevant characteristic of the fluid within the in-line mixingsystem 300.

The memory 306 may store instructions 310 to determine a corrected ratioof fluids being mixed in a blending operation. The corrected ratio maybe based on a specified blend ratio (e.g., a ratio of fluids to beblended at specific percentages for a blending operation), the previousdetermined blend ratio, the currently measure characteristics of thefluid within the in-line mixing system. Using the currently determinedblend ratio and the specified blend ratio, the controller 302 maydetermine a corrected blend ratio. The corrected blend ratio may includeindications as to what particular flow rates may require adjustment(e.g., what position a control may be adjusted to, to drive a blend tothe corrected ratio). In some examples, the signal may include positionsof control valves (e.g., the position one or more of the control valvesmay adjust to, to drive a blend to the corrected ratio), speed of a pump(e.g., to increase or decrease a particular component of a blend), oradjustment of another flow control device of the in-line mixing system300.

The memory 306 may include instructions 312. Instructions 312 mayinclude transmitting a signal to a device indicating a position for thedevice to adjust to, to control flow of liquid through the mixing jumper(e.g., via adjusting position of a jumper control valve 322A-322N). Thesignal may be transmitted from an output or input/output of thecontroller 302 to the device. Other flow control devices may beadjusted. Such adjustments may drive a blend to the corrected blendratio and thus to the specified blend ratio. In other words, flow may beincreased or decreased through one particular mixing jumper, whileincreased or decreased in another mixing jumper to correct an alteredblend ratio (e.g., such alteration occurring based on various factors,such as variable flow rates based on operating conditions or tank levelsand/or other factors). For example, the controller 302 may poll a tanklevel meter or gauge periodically (e.g., determine a tank level atselected times or substantially continuously). As the tank leveldecreases overtime, the controller 302 may automatically adjust an openposition of a corresponding control valve to offset any fluid flow ratereduction based on the measured tank level (e.g., increase the openposition to adjust for decreasing tank levels and/or decrease openposition to adjust for increasing tank levels).

In an embodiment, the memory 306 may include instructions related toblend operation initiation. Such instructions may include the opening orclosing of isolation valves (e.g., main isolation valves 318A-318N, alsoreferred to as a main valve, and jumper isolation valves 320A-32N, alsoreferred to as a jumper valve). For example, for a single fluidoperation, a main isolation valve corresponding to a tank in theoperation may open, while the corresponding jumper control valve mayclose. In another embodiment, for a multiple component blend, thecontroller may indicate to two or more main isolation valves to closeand two or more jumper control valves to open.

In another embodiment, the memory 306 may store instructions to driveflow rates of any particular fluid utilized in a blend operation to aspecific set point. For example, a user may set a specific flow rate fortwo or more different fluids for a particular blend operation. Thecontroller 302 may determine, based on meters and/or sensors positionedat each mixing jumper, a flow rate. If the flow rate does not match, thecontroller 302 may transmit a signal to any particular control valve toadjust the flow rate of a corresponding fluid to the set point flowrate.

FIG. 4 is a flow diagram, such as implemented in a controller, of amethod 400 for managing a multi-component in-line mixing systemaccording to an embodiment of the disclosure. according to an embodimentof the disclosure. The method 400 is detailed with reference to thecontroller 302 and in-line mixing system 300 of FIG. 3. Unless otherwisespecified, the actions of method 400 may be completed within thecontroller 300, for example, but it also may be implemented in othersystems and/or computing devices as will be understood by those skilledin the art. Specifically, method 400 may be included in one or moreprograms, protocols, or instructions loaded into the memory 306 of thecontroller 302 and executed on the processor 304 or one or moreprocessors of the controller 302. The order in which the operations aredescribed is not intended to be construed as a limitation, and anynumber of the described blocks may be combined in any order and/or inparallel to implement the method 400.

At block 402, a controller 302 may receive blend parameters for ablending operation. The blend parameters may include a ratio of one ormore different liquids from one or more corresponding tanks. The blendparameters may additionally include a length of time of the blendoperation. Other factors or variables may be included in the blendparameters, including type of fluids, gravity or density of the fluids,and/or other relevant information. Blend parameters may be received fromother computing devices or controllers or, in another embodiment, from auser interface 314.

At block 404, the controller 302 may determine whether the blend is asingle component blend or, in other words, whether the desired endproduct includes a single type of fluid. Such a determination may bemade based on the blend parameters received or based on input receivedat a user interface 314.

At block 406, if the blend operation includes a single tank, thecontroller may transmit a signal to a corresponding main isolation valveto open. As no other tanks may be utilized in such an operation, thecorresponding main isolation valve may receive the signal, rather thanall main isolation valves.

At block 408, after the main isolation valve is open, the controller 302may transmit a signal to the jumper isolation valve to close. Thecontroller 302 may transmit such a signal to the corresponding jumperisolation valve, rather than all jumper isolation valves. At block 410,controller 302 may wait until such an operation is finished. Once theoperation is finished, the controller 302 may wait until new blendparameters are received.

At block 412, if the blend includes two or more tanks, the controller302 may transmit a signal to corresponding jumper isolation valves toopen. At block 414, the controller 302 may transmit a signal tocorresponding main isolation valves to close.

At block 416, after the blending operation has been initiated, thecontroller 302 may measure a fluid pressure, fluid flow, fluid density,and/or a tank level for each tank utilized. Such receivedcharacteristics or measurements may depend on the type of meters and/orsensors included in the in-line mixing system.

At block 418, based on the received characteristics, the controller 302may determine a current mix ratio (e.g., the current blend ratio of theblending operation). At block 420, the controller may determine whetherthe mix ratio is correct or within a percentage of error (e.g., 0.1%,0.2%, 0.3%, or up to 1%). If the mix ratio is not correct, thecontroller 302 may move to block 422. If the mix ratio is correct, thecontroller 302 may move to block 426.

At block 422, the controller 302 may determine a corrected ratio. Thecorrect ratio may be based on the received blend parameters and thecurrent mix ratio. At block 424, the controller 302, based on thecorrected ratio, may adjust corresponding control valves. At block 426,the controller 302 may determine whether the blend operation isfinished. If the operation is not finished, the controller 302 maycontinue to check measurements and adjust accordingly, otherwise thecontroller 302 may wait to receive new blend parameters.

FIG. 5 is another flow diagram, such as implemented in a controller, ofa method 500 for managing a multi-component in-line mixing systemaccording to an embodiment of the disclosure. according to an embodimentof the disclosure. The method 500 is detailed with reference to thecontroller 302 and in-line mixing system 300 of FIG. 3. Unless otherwisespecified, the actions of method 500 may be completed within thecontroller 300, for example, but it also may be implemented in othersystems and/or computing devices as will be understood by those skilledin the art. Specifically, method 500 may be included in one or moreprograms, protocols, or instructions loaded into the memory 306 of thecontroller 302 and executed on the processor 304 or one or moreprocessors of the controller 302. The order in which the operations aredescribed is not intended to be construed as a limitation, and anynumber of the described blocks may be combined in any order and/or inparallel to implement the method 500.

At block 502, a controller 302 may initiate a hydrocarbon liquid process(e.g., a blend operation or blend process). The controller 302 maydetermine that the hydrocarbon liquid process is to be initiated basedon one or more of reception of blend parameters or an input from a user,another controller, or other computing device. Such an input may includea signal indicating that the hydrocarbon liquid process is to begin. Theblend parameters may include a ratio of one or more different liquidsfrom one or more corresponding tanks. The blend parameters mayadditionally include a length of time of the hydrocarbon liquid process.Other factors or variables may be included in the blend parameters,including type of fluids, gravity or density of the fluids, and/or otherrelevant information. Blend parameters may be received from othercomputing devices or controllers or, in another embodiment, from a userinterface 314.

At block 504, the controller 302 may transmit a signal to main valves(e.g., main valves of tanks to be utilized or corresponding to ahydrocarbon liquid in the hydrocarbon liquid process) to close. At block506, the controller 302 may transmit a signal to corresponding jumpervalves (e.g., jumper valves of tanks to be utilized or corresponding toa hydrocarbon liquid in the hydrocarbon liquid process) to open. Oncethe jumper valves are open and the main valves are closed, thecontroller 302 may begin the hydrocarbon liquid process (e.g., thecontroller 302 or a user opening a port or valve (via manual actuationor based on a signal received from the controller 302) on a tank toallow a hydrocarbon liquid to flow from the tank to the jumper valves).

At block 508, after the hydrocarbon liquid process has begun, thecontroller 302 may measure a flow rate of each hydrocarbon liquidflowing to a mixing pipe or pipeline or header. The controller 302 mayadditionally measure fluid pressure, fluid density, and/or a tank levelfor each tank utilized. Such received characteristics or measurementsmay depend on the type of meters and/or sensors included in the in-linemixing system.

At block 510, based on the received flow rate and/or othercharacteristics, the controller 302 may determine a current mix ratio(e.g., the current blend ratio of the blending operation) and determinewhether the current mix ratio is different (e.g., within a percentage oferror, such as within 0.1%, 0.2%, 0.3%, or up to 1%) than a selected orpre-set mix ratio (e.g., the selected or pre-set mix ratio, for example,included in the blend parameters). If the mix ratio is not different oris within a percentage of error, the controller 302 may move to block516 and determine whether the hydrocarbon liquid process is finished orcomplete. If the mix ratio is different or not within a percentage oferror, the controller 302 may move to block 512 to determine a correctedratio.

At block 512, the controller 302 may determine a corrected ratio. Thecorrect ratio may be based on the received blend parameters and thecurrent mix ratio. At block 514, the controller 302, based on thecorrected ratio, may adjust corresponding control valves. At block 516,the controller 302 may determine whether the hydrocarbon liquid processis finished. If the operation is not finished, the controller 302 maycontinue to check measurements and adjust accordingly, otherwise thecontroller 302 may wait to receive new blend parameters or initiateanother hydrocarbon liquid process.

The present application claims priority to and the benefit of U.S.Application No. 63/265,458, filed Dec. 15, 2021, titled “METHODS ANDSYSTEMS FOR IN-LINE MIXING OF HYDROCARBON LIQUIDS” and U.S. ApplicationNo. 63/265,425, filed Dec. 15, 2021, titled “METHODS AND SYSTEMS FORIN-LINE MIXING OF HYDROCARBON LIQUIDS”, the disclosures of which areincorporated herein by reference in their entireties. The presentapplication is also a Continuation-in-Part of U.S. application Ser. No.17/566,768, filed Dec. 31, 2021, titled “METHODS AND SYSTEMS FORSPILLBACK CONTROL OF IN-LINE MIXING OF HYDROCARBON LIQUIDS”, which is acontinuation of U.S. application Ser. No. 17/247,880, filed Dec. 29,2020, titled “METHODS AND SYSTEMS FOR INLINE MIXING OF HYDROCARBONLIQUIDS BASED ON DENSITY OR GRAVITY”, now U.S. Pat. No. 11,247,184,issued Feb. 15, 2022, which is a Continuation-in-Part of U.S.application Ser. No. 17/247,700, filed Dec. 21, 2020, titled “METHODSAND SYSTEMS FOR INLINE MIXING OF HYDROCARBON LIQUIDS BASED ON DENSITY ORGRAVITY”, which claims priority to and the benefit of U.S.

Provisional Application No. 63/198,356, filed Oct. 13, 2020, titled“METHODS AND SYSTEMS FOR INLINE MIXING OF PETROLEUM LIQUIDS,” U.S.Provisional Application No. 62/705,538, filed Jul. 2, 2020, titled“METHODS AND SYSTEMS FOR INLINE MIXING OF PETROLEUM LIQUIDS”, and U.S.Provisional Application No. 62/954,960, filed Dec. 30, 2019, titled“METHOD AND APPARATUS FOR INLINE MIXING OF HEAVY CRUDE”, the disclosuresof which are incorporated herein by reference in their entirety. U.S.application Ser. No. 17/247,880 is also a Continuation-in-Part of U.S.application Ser. No. 17/247,704, filed Dec. 21, 2020, titled “METHODSAND SYSTEMS FOR INLINE MIXING OF HYDROCARBON LIQUIDS”, now U.S. Pat. No.10,990,114, issued Apr. 27, 2021, which claims priority to and thebenefit of U.S. Provisional Application No. 63/198,356, filed Oct. 13,2020, titled “METHODS AND SYSTEMS FOR INLINE MIXING OF PETROLEUMLIQUIDS,” U.S. Provisional Application No. 62/705,538, filed Jul. 2,2020, titled “METHODS AND SYSTEMS FOR INLINE MIXING OF PETROLEUMLIQUIDS”, and U.S. Provisional Application No. 62/954,960, filed Dec.30, 2019, titled “METHOD AND APPARATUS FOR INLINE MIXING OF HEAVYCRUDE”, the disclosures of which are incorporated herein by reference intheir entireties.

In the drawings and specification, several embodiments of systems andmethods to provide in-line mixing of hydrocarbon liquids have beendisclosed, and although specific terms are employed, the terms are usedin a descriptive sense only and not for purposes of limitation.Embodiments of systems and methods have been described in considerabledetail with specific reference to the illustrated embodiments. However,it will be apparent that various modifications and changes may be madewithin the spirit and scope of the embodiments of systems and methods asdescribed in the foregoing specification, and such modifications andchanges are to be considered equivalents and part of this disclosure.

What is claimed is:
 1. An in-line liquid mixing system positioned at atank farm to admix hydrocarbon liquids from a plurality of tanks into asingle pipeline, the in-line liquid mixing system comprising: two ormore tanks positioned at a tank farm with at least one tank containing ahydrocarbon liquid therein; two or more first main pipes, each one ofthe two or more main pipes connected to one of the two or more tanks;two or more main valves, each of the two or more main valves connectedto one of the two or more main pipes, the hydrocarbon liquid flowingfrom one tank through one first main pipe to a corresponding main valve;two or more second main pipes, each one of the two or more second mainpipes connected to a corresponding main valve; two or more mixingjumpers, each of the mixing jumpers connected to a corresponding firstmain pipe of the two or more first main pipes, each of the two or moremixing jumpers to, when a corresponding main valve is closed, controlhydrocarbon liquid flowing from two or more tanks; and a mixing pipeconnected to each of the two or more second main pipes and each of thetwo or more mixing jumpers, the mixing pipe configured to transporthydrocarbon liquid from one or more of the two or more tanks.
 2. Thein-line liquid mixing system of claim 1, wherein each of the one or moremixing jumpers include: an isolation valve to, when closed, preventhydrocarbon liquid to flow therethrough and, when open, allowhydrocarbon liquid to flow therethrough; a sensor to determine acharacteristic of hydrocarbon liquid flowing through the one of the oneor more mixing jumpers; a flow control device to control hydrocarbonliquid flowing through the one of the one or more mixing jumpers; and amixing jumper pipe to connect the mixing jumper to the mixing pipe orcorresponding second main pipe.
 3. The in-line liquid mixing system ofclaim 2, wherein the flow control device is one or more of a controlvalve or a turbine.
 4. The in-line liquid mixing system of claim 2,wherein the sensor is one or more of a flow meter, density sensor,pressure sensor or transducer, or a temperature sensor.
 5. The in-lineliquid mixing system of claim 2, wherein, when any one of the one ormore main valves is open and hydrocarbon liquid is flowing therethrough,each of the isolation valves for the one or more mixing jumpers isclosed.
 6. The in-line liquid mixing system of claim 2, furthercomprising one or more controllers in signal communication with theisolation valve, the sensor, and the flow control device of each of themixing jumpers and with each of the one or more main valves.
 7. Thein-line liquid mixing system of claim 6, wherein the one or morecontrollers controls the flow control device for each of the one or moremixing jumpers thereby to control an amount of hydrocarbon liquidflowing therethrough.
 8. The in-line liquid mixing system of claim 7,wherein the characteristic is a flow rate, and wherein the amount ofhydrocarbon liquid flowing through one or more of the flow controldevices of each of the one or more mixing jumpers is further based onone or more of a specified hydrocarbon liquid blend percentage and acurrent flow rate, from a corresponding sensor, of a specifiedhydrocarbon liquid flowing from a specified tank.
 9. The in-line liquidmixing system of claim 8, further comprising one or more sensorscorresponding to each of the two or more tanks.
 10. The in-line liquidmixing system of claim 9, wherein the one or more controllers determine,via each of the one or more sensors, a tank level or hydrocarbon liquiddensity.
 11. The in-line liquid mixing system of claim 10, wherein theamount of hydrocarbon liquid flowing through the one or more of the flowcontrol devices is further based on one or more of tank level orhydrocarbon liquid density corresponding to each of the two or tanks.12. The in-line liquid mixing system of claim 1, wherein pipesassociated with each of the one or more mixing jumpers comprise a16-inch diameter, and wherein each of the two or more first main pipesand each of the two or more second main pipes comprise a 36-inchdiameter.
 13. The in-line liquid mixing system of claim 1, wherein eachof the two or more main valves comprise an isolation valve, and whereinthe isolation valve includes an open position and a closed position. 14.The in-line liquid mixing system of claim 1, further comprising a pumppositioned along the mixing pipe and downstream of a point where each ofthe two or more second main pipes and each of the two or more mixingjumpers connects to the mixing pipe.
 15. The in-line liquid mixingsystem of claim 1, wherein the hydrocarbon liquid includes one or moreof a petroleum liquid or a renewable liquid.
 16. The in-line liquidmixing system of claim 15, wherein the renewable liquid includes one ormore of bio-fuel, pyrolysis oil, oleaginous feedstock, or biomassderived feedstock.
 17. The in-line liquid mixing system of claim 1,wherein the mixing pipe is a pipe including a plurality of connectors toconnect each of the two or more second main pipes and each of the two ormore mixing jumpers.
 18. The in-line liquid mixing system of claim 1,wherein the mixing pipe is a header.
 19. A method of admixing liquidfrom two or more tanks into a single pipeline to provide in-line mixingthereof, the method comprising: initiating a hydrocarbon liquid processthat includes blending specified percentages of two or more hydrocarbonliquids over a period of time each of the two or more hydrocarbonliquids stored in one of two or more tanks; closing, for each one of thetwo or more tanks, a main valve; opening, for each one of the two ormore tanks, an isolation valve of a mixing jumper; determining, for themixing jumper of each one of the two or more tanks, a flow rate ofhydrocarbon liquid; and in response to a difference between a mix ratioand a ratio of each determined flow rate of hydrocarbon liquid:determining a corrected ratio based on one or more of the differencebetween the mix ratio, the ratio of each determined flow rate ofhydrocarbon liquid, or one or more of each flow rate of each hydrocarbonliquid, and adjusting a flow control device of the mixing jumper foreach of the two or more tanks based on the corrected ratio to modifyflow rate of hydrocarbon liquid to drive the ratio towards the targetratio.
 20. The method of claim 19, wherein the flow control device isone or more of a control valve, and wherein the flow rate of hydrocarbonliquid is adjusted based on an opened/closed position of the controlvalve.
 21. The method of claim 19, wherein the flow rate of hydrocarbonliquid is determined via a flow meter.
 22. The method of claim 19,further comprising determining a tank level for each one of the two ormore tanks.
 23. The method of claim 22, wherein the corrected ratio isfurther based on the tank level for each of the two or more tanks.
 24. Amethod of admixing liquid from two or more tanks into a single pipelineto provide in-line mixing thereof, the method comprising: receivingblend parameters of a blend process that includes specified percentagesof one or more hydrocarbon liquids; in response to blend parameters withtwo or more specified percentages of two or more hydrocarbon liquids,each of the two or more hydrocarbon liquids stored in correspondingtanks: opening, for each of the corresponding tanks, a jumper valve of amixing jumper; closing, for each of the corresponding tanks, a mainvalve; determining, for the mixing jumper of each of the correspondingtanks, a flow rate of hydrocarbon liquid; and in response to adifference between a mix ratio and a ratio of each determined flow rateof hydrocarbon liquid: determining a corrected ratio based on one ormore of the difference between the mix ratio, the ratio of eachdetermined flow rate of hydrocarbon liquid, or one or more of each flowrate of each hydrocarbon liquid, and adjusting a flow control device ofthe mixing jumper for each of the corresponding tanks based on thecorrected ratio to modify flow rate of hydrocarbon liquid to drive theratio towards the target ratio.
 25. The method of claim 24, furthercomprising: in response to blend parameters with a specified percentageof one hydrocarbon liquid: opening, for a corresponding tank, a mainactuated valve to allow the one hydrocarbon liquid to flow to a headertherethrough for a selected time, and closing, for the correspondingtank, a jumper actuated valve of a mixing jumper to prevent flow of theone hydrocarbon liquid through the mixing jumper.
 26. The method ofclaim 24, wherein the corrected ratio is further based on one or more ofa density of each of the two or more hydrocarbon liquids or a level ofhydrocarbon liquid in each of the corresponding tanks.
 27. A controllerfor an in-line mixing system for admixing liquids from a plurality ofsets of tanks into a single pipeline, the controller comprising: a firstinput in signal communication with a first meter to measure a first flowrate of the first liquid, the first meter being positioned along a firstmixing jumper that is connected to a first tank, the controllerconfigured to obtain the first flow rate from the first meter via thefirst input after initiation of a blending operation; a second input insignal communication with a second meter to measure a second flow rateof the second liquid, the second meter being positioned along a secondmixing jumper that is connected to a second tank, the controllerconfigured to obtain the second flow rate from the second meter via thesecond input after initiation of the blending operation; and aninput/output in signal communication with a first control valve, thefirst control valve designed to adjust flow of the first liquid via thefirst mixing jumper thereby modifying the first flow rate, and a secondcontrol valve, the second control valve designed to adjust flow of thesecond liquid via the second mixing jumper thereby modifying the secondflow rate, the controller configured to: after initiation of theblending operation: determine whether one or more of the first flow rateor the second flow rate are to be modified based on one or more of atarget mix ratio, a ratio of the first flow rate and second flow rate,the first flow rate, or the second flow rate, and in response to adetermination that the first flow rate is to be modified: adjust aposition of the first flow control valve that adjusts flow through thefirst mixing jumper, thereby modifying the first flow rate; and inresponse to a determination that the second flow rate is to be modified:adjust a position of the second flow control valve that adjusts flowthrough the second mixing jumper, thereby modifying the second flowrate.
 28. The controller of claim 27, further comprising a third inputin signal communication with a third meter to measure a level of liquidof the first tank, the controller configured to obtain the level ofliquid of the first tank from the third meter via the third input afterinitiation of the blending operation; and a fourth input in signalcommunication with a fourth meter to measure a level of liquid of thesecond tank, the controller configured to obtain the level of liquid ofthe second tank from the fourth meter via the fourth input afterinitiation of the blending operation.
 29. The controller of claim 28,wherein the level of liquid of the first tank and the level of liquid ofthe second tank are obtained by the controller continuously orintermittently.
 30. The controller of claim 28, wherein determination ofwhether one or more of the first flow rate or the second flow rate areto be modified is based on the level of liquid of the first tank and thelevel of liquid of the second tank.